Method and system to determine the geo-stresses regime factor q from borehole sonic measurement modeling

ABSTRACT

Methods and systems for analyzing subterranean formations in-situ stress are disclosed. A method for extracting geological horizon on-demand from a 3D seismic data set, comprises receiving sonic log data; computing the anisotropic shear moduli C 44 , C 55  and C 66 ; determining in-situ stress type and selecting an in-situ stress expression corresponding to the in-situ stress type; computing stress regime factor Q of the formation interval; and computing and outputting the maximum stress σ H  by using the stress regime factor Q, Vertical stress σ v  and Minimum horizontal stress σ h .

BACKGROUND OF INVENTION

1. Field of the Invention

The invention relates to method and system for borehole sonicmeasurement, more particularly, the invention relates to method andsystem for analyzing the formation rock in-situ stress.

2. Background Art

Extracting quantitative information of the formation rock stresses fromborehole log measurements is fundamental to the analysis and predictionof geo-mechanical problems encountered in the petroleum industry. Todaythere is no direct measurement to fully characterize the formation rockgeo-stresses tensor (three principal stresses and three angles todescribe the directions). For most of cases it can be reasonably assumedthat the vertical stress is one principal stress, so, there are fourparameters to describe the geo-stresses: vertical stress, minimumhorizontal, maximum horizontal stresses and the azimuth of minimumhorizontal stress. Thus, the in-situ stresses of a formation can berepresented by the vertical stress, maximum horizontal stress, minimumhorizontal stress, azimuth of minimum horizontal stress and the porepressure. The vertical stress may be estimated from an integral of thedensity log, while the minimum horizontal stress can be estimated usingfracturing or leak-off test data, and its direction from boreholecaliper or images analysis. However, the maximum horizontal stress ismore difficult to estimate, the conventional approach is to use somecorrelations such as the pore-elastic strain correlation, or theapproximations such as equating the maximum horizontal stress to somemultiple of the minimum horizontal stress.

However, these kinds of correlations for estimating maximum horizontalstress are always associated with big uncertainty. In addition, there isno correlation or model available to interpret directly from thevertical and minimum horizontal stresses logging to that of the maximumhorizontal stress. Recent developments in sonic logging involvemeasuring the formation rock anisotropic wave velocities induced byin-situ stress anisotropy, which have been discussed in the followingpatents and publications. (1) U.S. Pat. No. 5,838,633 issued to Sinha etal., discloses a method for formation stress magnitude and formationnon-linear parameters by using a high frequency sonic signal and a lowfrequency sonic signal; (2) U.S. patent application Ser. No. 12/413,178,Method to estimate subsurface principal stress directions and ellipsoidshape factor R from borehole sonic log anisotropy directions and imagelog failure directions, by Romain Prioul, et al.; (3) Colin M. Sayers,Sensitivity of elastic-wave velocities to stress changes in sandstones,The Leading Edge, December 2005, 1262-1266, discloses the relationbetween elastic-wave velocity change and the in-situ stress change; (4)U.S. Pat. No. 6,904,365 issued to Bratton, T. R. et al, discloses amethod for determining formation stress parameter by using radial stressprofile derived from the logging data and formation models; (5) Sarkar,D., Bakulin, A., and Kranz, R., 2003, Anisotropic inversion of seismicdata for stressed media: Theory and a physical modeling study on BereaSandstone: Geophysics, 68, 690-704, discusses modeling the relationshipbetween the magnitude of the principal stresses and anisotropicparameters; (6) Prioul, R., A. Bakulin, V. Bakulin (2004), Non-linearrock physics model for estimation of 3-D subsurface stress inanisotropic formations: Theory and laboratory verification, Geophysics,Vol. 69, pp. 415-425 and (7) U.S. Pat. No. 6,714,873, System and methodfor estimating subsurface principal stresses from seismic reflectiondata, issued to Bakulin, et al., discusses determining formation stresscharacteristics by using the relationship between the measured seismicdata and the known rock properties and elastic stiffness and/or sonicvelocity.

Accurate estimation of geological formation stresses is desirable in thehydrocarbon production business, because formation stress determinationis considered critical for hydrocarbon production planning, as well asproviding prediction of sanding and borehole stability. As a result,there is a growing demand in the art for accurate estimation ordetermination of formation stresses.

SUMMARY OF INVENTION

In one aspect, the invention relates to method for using the boreholesonic anisotropy measurement for analyzing in-situ stress. It can beused in the cases when the formation rock anisotropic shear modulus C₄₄,C₅₅ and C₆₆ could be obtained, either from borehole sonic tools, or fromseismic and other acoustic measurement.

The present invention relates to methods for analyzing in-situ stress,particularly computing maximum stress G_(H) from sonic log datarepresented in three dimensions (3D). A method in accordance with oneembodiment of the invention includes receiving a first log data and asecond log data; computing the anisotropic shear moduli C₄₄, C₅₅ and C₆₆by using the first log data; determining in-situ stress type based onthe anisotropic shear moduli C₄₄, C₅₅ and C₆₆ and selecting an in-situstress expression corresponding to the in-situ stress type; computingVertical stress σ_(v) and Minimum horizontal stress σ_(h) by using thesecond log data; computing stress regime factor Q of the formationinterval based on the in-situ stress type; and computing and outputtingthe maximum stress σ_(H) by using the stress regime factor Q, Verticalstress σ_(v) and Minimum horizontal stress σ_(h).

In another aspect, the present invention relates to systems foranalyzing formation in-situ stress. A system in accordance with oneembodiment of the invention includes a processor and a memory, whereinthe memory stores a program having instructions for: receiving a firstlog data and a second log data; computing the anisotropic shear moduliC₄₄, C₅₅ and C₆₆ by using the first log data; determining in-situ stresstype based on the anisotropic shear moduli C₄₄, C₅₅ and C₆₆ andselecting an in-situ stress expression corresponding to the in-situstress type; computing Vertical stress σ_(v) and Minimum horizontalstress σ_(h) by using the second log data; computing stress regimefactor Q of the formation interval based on the in-situ stress type; andcomputing and outputting the maximum stress σ_(H) by using the stressregime factor Q, Vertical stress σ_(v) and Minimum horizontal stressσ_(h.)

Another aspect of the invention relates to a computer-readable mediumstoring a program having instructions for: receiving a first log dataand a second log data; computing the anisotropic shear moduli C₄₄, C₅₅and C₆₆ by using the first log data; determining in-situ stress typebased on the anisotropic shear moduli C₄₄, C₅₅ and C₆₆ and selecting anin-situ stress expression corresponding to the in-situ stress type;computing Vertical stress σ_(v) and Minimum horizontal stress σ_(h) byusing the second log data; computing stress regime factor Q of theformation interval based on the in-situ stress type; and computing andoutputting the maximum stress σ_(H) by using the stress regime factor Q,Vertical stress σ_(v) and Minimum horizontal stress σ_(h).

Other aspects and advantages of the invention will become apparent fromthe following description and the attached claims.

BRIEF SUMMARY OF THE DRAWINGS

FIG. 1 a-1 c shows examples of three typical faults.

FIG. 2 a is a schematic representation of formation rock aroundborehole, also showing of stress in the rock, a sonic transmitter, a setof sonic receivers and a depth interval AB.

FIG. 2 b schematically illustrates a set of anisotropic shear moduliC₄₄, C₅₅ and C₆₆.

FIG. 3 shows a process of estimating in-situ stress and updating in-situstress models in accordance with one embodiment of the invention.

FIG. 4 shows a process of estimating maximum horizontal stress σ_(H) inaccordance with one embodiment of the invention.

FIG. 5 shows a display of a wellsite system in which the presentinvention can be employed with at least one embodiment of the invention.

FIG. 6 shows a display of a sonic logging-while-drilling device that canbe used with at least one embodiment of the invention.

FIG. 7 shows a schematic illustration of a computer system for use inconjunction with at least one embodiment of the present invention.

DETAILED DESCRIPTION

Embodiments of the invention relate to methods and systems for dataprocessing, particularly data represented in three dimensions (3D).Embodiments of the invention are particularly useful in processing dataobtained from oil and gas exploration, such as sonic logging. Forclarity, the following description may use sonic measurement dataprospecting to describe embodiments of the invention. However, one ofordinary skill in the art would appreciate that embodiments of theinvention may also be applied to other types of data.

Formation rock geo-stress can be fully characterized by a stress tensor(three principal stresses and three angles to describe the directions).For most of cases in deep formation, it can be reasonably assumed thatthe vertical stress is a principal stress. Thus, geo-stresses in arandom point within a formation can be represented by four parameters:vertical stress σ_(V), minimum horizontal σ_(h), maximum horizontalstresses σ_(H) and the azimuth of minimum horizontal stress. Thevertical stress may be estimated from an integral of the density log,while the minimum horizontal stress can be estimated using fracturing orleak-off test data, and the azimuth of minimum horizontal stress fromborehole caliper, images analysis or alternatively from sonic fast-shearazimuth. According to one embodiment of the present invention, a stressregime factor Q is introduced to characterize in-situ stress state andestimate maximum horizontal stress; and it helps to solve the difficultyin measuring maximum horizontal stress.

The Stress Regime factor Q indicates the degree of rock formationgeo-stress anisotropy. This concept of Stress Regime Factor Q can bededuced from stress parameters that are derived from boreholeinformation, such as, orientation of breakouts, stress induced fracturesand slips.

Assuming the three principal stresses as σ₁, σ₂ and σ₃ (total stresshere and σ₃<=σ₂<=σ₁), the stress ratio factor R is defined as:

$\begin{matrix}\begin{matrix}{R = \frac{\sigma_{2} - \sigma_{3}}{\sigma_{1} - \sigma_{3}}} & \left( {0 \leq R \leq 1} \right)\end{matrix} & (1)\end{matrix}$

As can be seen from the above equation, R represents only the degree ofanisotropy of the three principal stresses, but irrelevant to the orderof vertical stress σ_(V) comparing with the two horizontal stresses. Thevertical stress σ_(V) is a very important identification for stresscharacterization. As shown in FIG. 1, different stress orders representtotally different stress environments. Therefore, for the three maincategories of stress environments, the stress ratio factor R can berepresented as:

$\begin{matrix}{{{R_{1} = \frac{\sigma_{H} - \sigma_{h}}{\sigma_{V} - \sigma_{h}}}\mspace{14mu} {Where}\mspace{14mu} \sigma_{1}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Normal}\mspace{14mu} {fault}} \right)},{{i.e.\mspace{14mu} \sigma_{V}}>=\sigma_{H}>=\sigma_{h}}} & \; \\{{{R_{2} = {\frac{\sigma_{V} - \sigma_{h}}{\sigma_{H} - \sigma_{h}} = \frac{1}{R_{1}}}}\; {Where}\mspace{14mu} \sigma_{2}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Strike}\text{-}{slip}\mspace{14mu} {faults}} \right)},{{i.e.\mspace{14mu} \sigma_{H}}>=\sigma_{V}>=\sigma_{h}}} & \; \\{{{R_{3} = \frac{\sigma_{h} - \sigma_{V}}{\sigma_{H} - \sigma_{V}}}{Where}\mspace{14mu} \sigma_{3}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Thrust}\mspace{14mu} {faults}} \right)},{{i.e.\mspace{14mu} \sigma_{H}}>=\sigma_{h}>=\sigma_{V}}} & \;\end{matrix}$

Thus, Stress Regime factor Q is defined as follow:

$\begin{matrix}{{{Q = {R_{1} = \frac{\sigma_{H} - \sigma_{h}}{\sigma_{V} - \sigma_{h}}}}\mspace{14mu} {Where}\mspace{14mu} \sigma_{1}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Normal}\mspace{14mu} {fault}} \right)},{{i.e.\mspace{14mu} \sigma_{V}}>=\sigma_{H}>=\sigma_{h}}} & (2) \\{{{Q = {{2 - R_{2}} = {2 - \frac{\sigma_{V} - \sigma_{h}}{\sigma_{H} - \sigma_{h}}}}}\mspace{14mu} {Where}\mspace{14mu} \sigma_{2}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Strike}\text{-}{slip}\mspace{14mu} {faults}} \right)},{{i.e.\mspace{14mu} \sigma_{H}}>=\sigma_{V}>=\sigma_{h}}} & (3) \\{{Q = {{2 + R_{3}} = {2 + \frac{\sigma_{h} - \sigma_{V}}{\sigma_{H} - \sigma_{V}}}}}{{{Where}\mspace{14mu} \sigma_{3}\mspace{14mu} {is}\mspace{14mu} {the}\mspace{14mu} {vertical}\mspace{14mu} \left( {{Thrust}\mspace{14mu} {faults}} \right)},{{i.e.\mspace{14mu} \sigma_{H}}>=\sigma_{h}>=\sigma_{V}}}} & (4)\end{matrix}$

The advantage of the factor Q representation is that it presents notonly the degree of formation rock stress anisotropy, but also thecharacteristic of stress model. As shown in FIG. 1 a, for normal faultsstress regime, 0<=Q<=1; as shown in FIG. 1 b, for strike-slip faultsstress regime, 1<Q<=2; and as shown in FIG. 1 c, for thrust faultsstress regime, 2<Q<=3.

Sonic wave velocities in sedimentary formation are stress-dependent, andthe rock formation under the effect of anisotropic in-situ stresses(which is true for almost most of the cases) will exhibit anisotropicelasticity. With the development of advanced borehole sonic tools, suchas, but not limited to, Sonic Scanner tool available from Schlumberger,the anisotropic elastic behavior of formation rock can be measured andanalyzed.

As shown in FIG. 2 a, considering the situation that the formation rockburied under the vertical stress σ_(v), minimum horizontal stress σ_(h),maximum horizontal stress σ_(H), and pore pressure P_(p). Define a X₁,X₂, X₃-coordinate system where the borehole axis (X₃) is aligned withvertical stress σ_(V), and the X₁-axis is aligned with the direction ofσ_(H). As shown in FIG. 2 b, by using a sonic tool, three shear modulusof the formation, C₄₄, C₅₅ and C₆₆, can be calculated. The method ofdetermining anisotropic moduli of earth formations is disclosed in U.S.Pat. No. 6,714,480 issued to Sinha et al., the entire teaching isincorporated herein as reference. Here the Voigt conventional matrixnotation is used, wherein C₄₄ is the shear moduli in the plane of X₂-X₃(σ_(h) and σ_(V)), C₅₅ in the plane of X₃-X₁ (σ_(V) and σ_(H)) and C₆₆in the plane of X₁-X₂ (σ_(h) and σ_(H)).

Based on an assumption that the material is intrinsic isotropy (i.e. inthe absence of stress), and the perturbation theory of stress-dependentelastic model as described in U.S. Pat. No. 6,351,991, Determiningstress parameters of formations from multi-mode velocity data, by Sinha,et al., the anisotropic changes in elastic shear moduli C₄₄ and C₆₆,induced by the anisotropic stress (σ_(V), σ_(H), σ_(h) and pore pressureP_(p)) can be described as:

$\begin{matrix}{{{\Delta \; C_{44}} - {\Delta \; C_{66}}} = {{\begin{bmatrix}{\frac{E}{1 + \upsilon} + {2C_{44}} +} \\\left( {C_{155} - C_{144}} \right)\end{bmatrix} \cdot \frac{1 + \upsilon}{E}}\left( {{\Delta\sigma}_{V} - {\Delta\sigma}_{H}} \right)}} & (5)\end{matrix}$

where E , υ, and C₄₄ are the Young's modulus, Poisson's ratio, and shearmodulus of the formation in the chosen reference state (initial state);and C₁₅₅ and C₁₄₄ are the formation nonlinear constants in the referencestate. As all of these parameters are the elastic properties of materialin the reference state, which is by definition the isotropic condition,so equation 5 can be simplified as:

$\begin{matrix}{{{{\Delta \; C_{44}} - {\Delta \; C_{66}}} = {A\; {E \cdot \left( {{\Delta\sigma}_{V} - {\Delta\sigma}_{H}} \right)}}}{{Where}\text{:}}} & (6) \\{{A\; E} = {\left\lbrack {\frac{E}{1 + \upsilon} + {2C_{44}} + \left( {C_{155} - C_{144}} \right)} \right\rbrack \cdot \frac{1 + \upsilon}{E}}} & (7)\end{matrix}$

AE is the parameter representing the formation isotropic property atreference state (Initial state), which refers to the changes in elasticmoduli caused by the changes in stress applied to this propagatingmedium, it is not dependent on any direction.

Following the same philosophy, equations for (C₄₄-C₅₅) and (C₅₅-C₆₆) aregiven as follow:

ΔC ₄₄ −ΔC ₅₅ =AE·(Δσ_(h) −Δσ _(H))   (8)

ΔC ₅₅ =ΔC ₆₆ =AE·(Δσ_(V) −Δσ _(h))   (9)

For the intrinsic isotropic material such as sand formation, it can bereasonably assumed that a reference state of isotropic elastic moduli isunder the action of isotropic stress (isotropic stress σ⁰ and theisotropic shear moduli C₄₄ ⁰), and so it can also be give as follow:

ΔC ₄₄ =C ₄₄ −C ₄₄ ⁰ , ΔC ₅₅ =C ₅₅ −C ₄₄ ⁰ , ΔC ₆₆ =C ₆₆ −C ₄₄ ⁰

Δσ_(V)=σ_(V)−σ⁰, Δσ_(H)=σ_(H)−σ⁰, Δσ_(h)=σ_(h)−σ⁰   (10)

Substituting the above into equation 6, 8 and 9:

C ₆₆ −C ₄₄ =AE·(σ_(H) −σ _(V))   (11)

C ₄₄ −C ₅₅ =AE·(σ_(h) −σ _(H))   (12)

C ₅₅ −C ₆₆ =AE·(σ_(V)=σ_(h))   (13)

There are only two independent equations among equations (11), (12) and(13), rewrite as:

$\begin{matrix}{{\frac{\sigma_{H} - \sigma_{h}}{\sigma_{V} - \sigma_{h}} = {\frac{C_{55} - C_{44}}{C_{55} - C_{66}} = {R_{1} = \frac{1}{R_{2}}}}}\mspace{11mu}} & (14) \\{\frac{\sigma_{h} - \sigma_{V}}{\sigma_{H} - \sigma_{V}} = {\frac{C_{66} - C_{55}}{C_{66} - C_{44}} = R_{3}}} & (15)\end{matrix}$

The above expressions indicate the relationship between anisotropicshear moduli and anisotropic stress for the intrinsic isotropic medium,such as, a sand formation. According to one embodiment of the presentinvention, this correlation does not rely on the reference state (no σ⁰and C₄₄ ⁰ items in equations (14) and (1 5)) or the stress sensitivityproperty AE, even though it had been introduced in the above deductionprocess.

As for the model for the intrinsic anisotropic sedimentary formation,considering a relatively homogeneous shale interval buried in deepformation, and the increments of the stresses from top depth to deepdepth are Δσ_(V), Δσ_(H) and Δσ_(h), and the increment of pore pressureis ΔP_(R). The increment of anisotropic Shear moduli, ΔC₄₄, ΔC₅₅ andΔC₆₆ can be measured by sonic tools. Thus, it can reasonably be assumedthat the shale formation in this interval has the same degree ofintrinsic anisotropy, and the increase of shear moduli along from thetop to the depth, ΔC₄₄, ΔC₅₅ and ΔC₆₆ is caused by the increase ofstress. Based on this assumption, equation (5) can be approximated asfollow:

$\begin{matrix}{{{\Delta \; C_{44}} - {\Delta \; C_{66}}} \approx {{\begin{bmatrix}{\frac{E}{1 + \upsilon} + {2C_{44}^{0}} +} \\\left( {C_{155}^{0} - C_{144}^{0}} \right)\end{bmatrix} \cdot \frac{1 + \upsilon}{E}}\left( {{\Delta\sigma}_{V} - {\Delta\sigma}_{H}} \right)}} & (16)\end{matrix}$

Equation (1 6) appears similar to equation (5), but has a differentphysical meaning. In equation (5), differences are related to thereference state as explained in equation (10), while for the shalemodel, the difference is between the top and bottom of the choseninterval with a reasonably uniform lithology. Following the same steps:

$\begin{matrix}{\frac{{\Delta\sigma}_{H} - {\Delta\sigma}_{h}}{{\Delta\sigma}_{V} - {\Delta\sigma}_{h}} = \frac{{\Delta \; C_{55}} - {\Delta \; C_{44}}}{{\Delta \; C_{55}} - {\Delta \; C_{66}}}} & (17) \\{\frac{{\Delta\sigma}_{h} - {\Delta\sigma}_{V}}{{\Delta\sigma}_{H} - {\Delta\sigma}_{V}} = \frac{{\Delta \; C_{66}} - {\Delta \; C_{55}}}{{\Delta \; C_{66}} - {\Delta \; C_{44}}}} & (18)\end{matrix}$

These two equations clearly express the relation of stress increments tothat of anisotropic shear moduli in a relatively uniform lithology shaleinterval.

As for the relation between the Stress regime Q with the measured sonicanisotropy, substituting sand anisotropy model (equations 14 and 15)into Q equations, the model for sand formation will be given as follow:

For Normal fault stress regime (σ_(V)>=σ_(H)>=σ_(h)):

$\begin{matrix}{{Q = {\frac{\sigma_{H} - \sigma_{h}}{\sigma_{V} - \sigma_{h}} = {R_{1} = \frac{\; {C_{55} - \; C_{44}}}{\; {C_{55} - C_{66}}}}}}\left( {0 \leq Q \leq 1} \right)} & (19)\end{matrix}$

For Strike-slip fault stress regime (σ_(H)>=σ_(V)>=σ_(h)):

$\begin{matrix}{{Q = {{2 - \frac{\sigma_{V} - \sigma_{h}}{\sigma_{H} - \sigma_{h}}} = {{2 - R_{2}} = {2 - \frac{\; {C_{55} - \; C_{66}}}{\; {C_{55} - C_{44}}}}}}}\left( {1 < Q \leq 2} \right)} & (20)\end{matrix}$

For Thrust fault stress regime (σ_(H)>=σ_(h)>=σ_(V)):

$\begin{matrix}{{Q = {{2 + \frac{\sigma_{h} - \sigma_{V}}{\sigma_{H} - \sigma_{V}}} = {{2 + R_{3}} = {2 + \frac{\; {C_{66} - \; C_{55}}}{\; {C_{66} - C_{44}}}}}}}\left( {2 < Q \leq 3} \right)} & (21)\end{matrix}$

With the measured anisotropic shear moduli C₄₄, C₅₅, C₆₆ and the orderof their magnitudes, it can also be used directly to identify the stressregime. As shown in above equations, C₅₅>C₄₄>C₆₆ means the Normal faultsstress regime, C₅₅>C₆₆>C₄₄ means the Strike-slip stress regime andC₆₆>C₅₅>C₄₄ means the Thrust faults stress regime. Based on the abovediscussion, the stress regime factor Q can be extracted from the sonicdata, as summarized below:

Shear Moduli Ranking Stress Regime Q factor C₅₅ > C₄₄ > C₆₆ Normalfaults $0 \leq \frac{C_{55} - C_{44}}{C_{55} - C_{66}} \leq 1$ C₅₅ >C₆₆ > C₄₄ Strike-slip faults$1 < \frac{C_{55} + C_{66} - {2\; C_{44}}}{C_{55} - C_{44}} \leq 2$C₆₆ > C₅₅ > C₄₄ Thrust faults$2 < \frac{{3\; C_{66}} - {2\; C_{44}} - C_{55}}{C_{66} - C_{44}} \leq 3$

According to one embodiment of the present invention, the factor Q mayalso result from caliper & images analysis of borehole shape failure,such as breakout and induced fracture. The system for analyzing boreholeshape failure includes, but not limited to, BorStress system availablefrom Schlumberger. It can also be obtained using borehole sonicanisotropy directions (e.g. fast-shear azimuth also called FSA) in oneor multiple deviated boreholes, either independently or in combinationwith other data. More details of the process of obtaining factor Q byusing borehole sonic anisotropy directions in one or multiple deviatedboreholes is disclosed by a commonly owned U.S. patent application Ser.No. 12/413,178, Method to estimate subsurface principal stressdirections and ellipsoid shape factor R from borehole sonic loganisotropy directions and image log failure directions, by RomainPrioul, et al., the entire teaching is incorporated herein as reference.

According to one embodiment of the present invention and as shown inFIG. 3, a workflow for estimating the in-situ stresses comprisesreceiving a second log data 301, the second log data includes and notlimited to density log data, formation resistivity log, GR and porositylog data. Using the log data received at step 301, the following stepsare performed: Computing vertical stress σ_(V) by integrating thedensity log data 302, wherein the measurement of rock bulk density canbe performed using standard nuclear logging tools from the surface tothe depth of interest (and then integrated over depth); Computing porepressure P_(p) by using standard models or correlations 303, wherein themodels or the correlations are suitable for the field and calibratingthe results with available data or measurement, more details of themethod for computing pore pressure is disclosed by the commonly ownedU.S. Pat. No. 6,351,991, Determining stress parameters of formationsfrom multi-mode velocity data, issued to Sinha, et al., the entireteaching is incorporated herein as reference; Computing minimumhorizontal stress σ_(h) by using some standard models, more detail ofthe process for computing horizontal stress is disclosed in Haimson, B.C., F. H. Cornet, ISRM Suggested Methods for rock stress estimation Part3: hydraulic fracturing (HF) and/or hydraulic testing of pre-existingfractures (HTPF), International Journal of Rock Mechanics & MiningSciences 40 (2003) 10111020, and calibrating the result with leak-offtest data or other test data 304; and Generating formation intervals305.

As shown in FIG. 3, the workflow for estimating the in-situ stress alsocomprises receiving the first log data 321. The first log data includessonic log data, which could be obtained through Sonic Scanner availablefrom Schlumberger. The received sonic log data are then interpreted forcomputing the anisotropic shear moduli C₄₄, C₅₅ and C₆₆ at step 322.Using the formation intervals derived at step 305 and the anisotropicshear moduli C₄₄, C₅₅ and C₆₆ corresponding to a formation interval, thestress regime factor Q in the formation interval can be computed at step323. According to the order of the magnitude of the anisotropic shearmoduli C₄₄, C₅₅ and C₆₆, the corresponding stress type is determinedfrom Normal faults, Strike-slip faults and Thrust faults, and acorrelation for calculating stress regime factor Q is selected from oneof the three equations. Then, the stress regime factor Q will be usedtogether with the vertical stress σ_(V) derived at step 302 and theminimum horizontal stress σ_(h) derived at step 304 to compute themaximum horizontal stress σ_(H). Finally, at step 326, output the Insitu stress including the vertical stress σ_(V), the minimum horizontalstress σ_(h), the maximum horizontal stress σ_(H) pore pressure P_(p)and the azimuth of minimum horizontal stress corresponding to theformation interval.

According to one embodiment of the present invention and as shown inFIG. 4, a workflow for estimating maximum horizontal stress σ_(H) of adesired formation interval starts with receiving sonic log data at step401. Interpreting the received sonic log data and computing theanisotropic shear moduli C₄₄, C₅₅ and C₆₆ at step 402, which includereceiving compressional, fast shear, slow shear and Stoneley velocities;receiving formation mass density and mud density data and determiningthe anisotropic shear moduli C₄₄, C₅₅ and C₆₆ by using the receiveddata. More details of the method for computing the anisotropic shearmoduli C₄₄, C₅₅ and C₆₆ are disclosed in U.S. Pat. No. 6,351,991 issuedto Sinha et al., the entire teaching is incorporated herein asreference. The magnitude of the moduli C₄₄, C₅₅ and C₆₆ are thencompared in step 403. According to the order of the magnitudes of themoduli C₄₄, C₅₅ and C₆₆, stress regime factor Q can be computed by usingone of the equations (19), (20) and (21). Receiving the vertical stressσ_(V) 405 derived from density log and receiving the minimum horizontalstress σ_(h) 406 derived from modeling and calibration. By using theσ_(V) and σ_(h) together with Q, the maximum horizontal stress σ_(H) canbe computed with the corresponding equation selected from equations(19), (20) and (21).

According to one embodiment of the present invention, a wellsite systemin which the present invention can be employed is shown in FIG. 5. Thewellsite can be onshore or offshore. In this exemplary system, aborehole 11 is formed in subsurface formations by rotary drilling in amanner that is well known. Embodiments of the invention are notrestricted to be used in vertical wells, and embodiments of theinvention can also use directional drilling, as will be describedhereinafter.

Still referring to FIG. 5, a drill string 12 is suspended within theborehole 11 and has a bottom hole assembly 100 which includes a drillbit 105 at its lower end. The surface system includes platform andderrick assembly 10 positioned over the borehole 11, the assembly 10including a rotary table 16, kelly 17, hook 18 and rotary swivel 19. Thedrill string 12 is rotated by the rotary table 16, energized by meansnot shown, which engages the kelly 17 at the upper end of the drillstring. The drill string 12 is suspended from a hook 18, attached to atraveling block (also not shown), through the kelly 17 and a rotaryswivel 19 which permits rotation of the drill string relative to thehook. As is well known, a top drive system could alternatively be used.

Also referring to FIG. 5, according to the example of this embodiment,the surface system further includes drilling fluid or mud 26 stored in apit 27 formed at the well site. A pump 29 delivers the drilling fluid 26to the interior of the drill string 12 via a port in the swivel 19,causing the drilling fluid to flow downwardly through the drill string12 as indicated by the directional arrow 8. The drilling fluid exits thedrill string 12 via ports in the drill bit 105, and then circulatesupwardly through the annulus region between the outside of the drillstring and the wall of the borehole, as indicated by the directionalarrows 9. In this well known manner, the drilling fluid lubricates thedrill bit 105 and carries formation cuttings up to the surface as it isreturned to the pit 27 for recirculation.

The bottom hole assembly 100 of the illustrated embodiment alogging-whiledrilling (LWD) module 120, a measuring-while-drilling (MWD)module 130, a rotor-steerable system and motor, and drill bit 105.

The LWD module 120 is housed in a special type of drill collar, as isknown in the art, and can contain one or a plurality of known types oflogging tools. It will also be understood that more than one LWD and/orMWD module can be employed, e.g. as represented at 120A. (References,throughout, to a module at the position of 120 can alternatively mean amodule at the position of 120A as well.) The LWD module includescapabilities for measuring, processing, and storing information, as wellas for communicating with the surface equipment. In the presentembodiment, the LWD module includes a sonic measuring device.

The MWD module 130 is also housed in a special type of drill collar, asis known in the art, and can contain one or more devices for measuringcharacteristics of the drill string and drill bit. The MWD tool furtherincludes an apparatus (not shown) for generating electrical power to thedownhole system. This may typically include a mud turbine generatorpowered by the flow of the drilling fluid, it being understood thatother power and/or battery systems may be employed. In the presentembodiment, the MWD module includes one or more of the following typesof measuring devices: a weight-on-bit measuring device, a torquemeasuring device, a vibration measuring device, a shock measuringdevice, a stick slip measuring device, a direction measuring device, andan inclination measuring device.

FIG. 6 illustrates a sonic logging-while-drilling tool which is alsoshown in FIG. 5 as LWD tool 120, or can be a part of an LWD tool suite120A. More details about the LWD tool is disclosed by U.S. Pat. No.6,308,137, the entire teaching of which is incorporated herein byreference. According to one embodiment of the present invention, asshown in FIG. 6, an offshore rig 810 is employed, and a sonictransmitting source or array 814 is deployed near the surface of thewater. Alternatively, any other suitable type of uphole or downholesource or transmitter can be provided. An uphole processor controls thefiring of the transmitter 814. The uphole equipment can also includeacoustic receivers and a recorder for capturing reference signals nearthe source. The uphole equipment further includes telemetry equipmentfor receiving MWD signals from the downhole equipment. The telemetryequipment and the recorder are typically coupled to a processor so thatrecordings may be synchronized using uphole and downhole clocks. Thedownhole LWD module 800 includes at least acoustic receivers 831 and832, which are coupled to a signal processor so that recordings may bemade of signals detected by the receivers in synchronization with thefiring of the signal source.

According to one embodiment of the invention, a system for estimatingin-situ stress is shown in FIG. 7. The system includes Memory 1104 (alsoreferred to as a computer-readable medium) is coupled to bus 1112 forstoring data and instructions to execute the workflow as shown in FIGS.3 and 4, by processor 1102. Memory 1104 also may be used for storingtemporary variables or other intermediate information during executionof instructions to be executed by processor 1102. Memory 1104 may alsocomprise a read only memory (ROM) or other static storage device coupledto bus 1112 for storing static information and instructions forprocessor 1102.

Network I/F 1106 comprises a mechanism for connecting to another device.In at least some embodiments, system 1100 comprises more than a singlenetwork interface.

A storage device (storage 1108), such as a magnetic disk or opticaldisk, may also be provided and coupled to the bus 1112 for storing dataand/or instructions to execute the workflow as shown in FIGS. 3 and 4.

I/O device may comprise an input device, an output device and/or acombined input/output device for enabling user interaction with system1100. An input device may comprise, for example, a keyboard, keypad,mouse, trackball, trackpad, cursor direction keys and/or an A/D card forreceiving log data, sonic log data and Geological field data asillustrated in FIG. 3 and communicating information and commands toprocessor 1102. An output device may comprise, for example, a display, aprinter, a voice synthesizer and/or a D/A card for outputting in-situstress or in-situ stress regime, and communicating information to auser.

The functions of a method or the workflow described in connection withthe embodiments disclosed herein may be embodied in hardware, executableinstructions embodied in a computer-readable medium, or a combinationthereof. Software comprising instructions for execution may reside in acomputer-readable medium comprising volatile and/or non-volatile memory,e.g., a random access memory, a read only memory, a programmable memory,a hard disk, a compact disc, or another form of storage medium readable,directly or indirectly, by a processing device.

While the invention has been described with respect to a limited numberof embodiments, those skilled in the art, having benefit of thisdisclosure, will appreciate that other embodiments can be envisionedthat do not depart from the scope of the invention as disclosed herein.Accordingly, the scope of the invention shall be limited only by theattached claims.

1. A method for analyzing in-situ stress of a formation interval,comprising: receiving a first log data and a second log data; computingthe anisotropic shear moduli C₄₄, C₅₅ and C₆₆ by using the first logdata; determining in-situ stress type based on the anisotropic shearmoduli C₄₄, C₅₅ and C₆₆ and selecting an in-situ stress expressioncorresponding to the in-situ stress type; computing Vertical stressσ_(v) and Minimum horizontal stress σ_(h) by using the second log data;computing stress regime factor Q of the formation interval based on thein-situ stress type; and computing and outputting the maximum stressσ_(H) by using the stress regime factor Q, Vertical stress σ_(v) andMinimum horizontal stress σ_(h).
 2. The method of claim 1, whereindetermining in-situ stress type and selecting an in-situ stressexpression comprising:${{{if}\mspace{14mu} C_{55}} > C_{44} > C_{66}},{{Q = {\frac{\sigma_{H} - \sigma_{h}}{\sigma_{V} - \sigma_{h}} = \frac{\; {C_{55} - \; C_{44}}}{\; {C_{55} - C_{66}}}}};}$${{{if}\mspace{14mu} C_{55}} > C_{66} > C_{44}},{{Q = {{2 - \frac{\sigma_{V} - \sigma_{h}}{\sigma_{H} - \sigma_{h}}} = {2 - \frac{\; {C_{55} - \; C_{66}}}{\; {C_{55} - C_{44}}}}}};\mspace{14mu} {and}}$${{{if}\mspace{14mu} C_{66}} > C_{55} > C_{44}},{Q = {{2 + \frac{\sigma_{h} - \sigma_{V}}{\sigma_{H} - \sigma_{V}}} = {2 + {\frac{\; {C_{66} - \; C_{55}}}{\; {C_{66} - C_{44}}}.}}}}$3. The method of claim 1, wherein the first log data includes sonic logdata, and the second log data include density log data, formationresistivity log data, GR and porosity log data and borehole image logdata.
 4. The method of claim 3, wherein the Vertical stress σ_(v) iscomputed by integrating the density log data from surface to the depthof the desired formation interval.
 5. The method of claim 3, wherein theMinimum horizontal stress σ_(h) is computed by standard models andcalibrated with leak-off test data.
 6. The method of claim 3 furthercomprising generating formation intervals by using the second log data.7. The method of claim 6, wherein computing stress regime factor Qincludes selecting a desired formation interval and computing stressregime factor Q of the formation interval.
 8. The method of claim 1further comprising receiving Geological field data and caliper data. 9.The method of claim 8 further comprising computing stress regime andazimuth of the minimum horizontal stress with the Geological field dataand caliper data by in-situ stress models.
 10. The method of claim 9further comprising comparing the stress regime factor Q derived from thesonic log data with the stress regime derived from the Geological fielddata.
 11. A system for analyzing in-situ stress of a formation interval,comprising a processor and a memory, wherein the memory stores a programhaving instructions for: receiving a first log data and a second logdata; computing the anisotropic shear moduli C₄₄, C₅₅ and C₆₆ by usingthe first log data; determining in-situ stress type based on theanisotropic shear moduli C₄₄, C₅₅ and C₆₆ and selecting an in-situstress expression corresponding to the in-situ stress type; computingVertical stress σ_(v) and Minimum horizontal stress σ_(h) by using thesecond log data; computing stress regime factor Q of the formationinterval based on the in-situ stress type; and computing and outputtingthe maximum stress σ_(H) by using the stress regime factor Q, Verticalstress σ_(v) and Minimum horizontal stress σ_(h).
 12. Acomputer-readable medium storing a program having instructions for:receiving a first log data and a second log data; computing theanisotropic shear moduli C₄₄, C₅₅ and C₆₆ by using the first log data;determining in-situ stress type based on the anisotropic shear moduliC₄₄, C₅₅ and C₆₆ and selecting an in-situ stress expressioncorresponding to the in-situ stress type; computing Vertical stressσ_(v) and Minimum horizontal stress σ_(h) by using the second log data;computing stress regime factor Q of the formation interval based on thein-situ stress type; and computing and outputting the maximum stressσ_(H) by using the stress regime factor Q, Vertical stress σ_(v) andMinimum horizontal stress σ_(h).